Equivalent circulating density control in deep water drilling

ABSTRACT

A method of providing a substantially constant rheological profile of a drilling fluid over a temperature range of about 120° F. to about 40° F. includes adding a drilling fluid additive to the drilling fluid, wherein the drilling fluid additive includes the reaction product of a carboxylic acid with at least two carboxylic moieties; and a polyamine having an amine functionality of two or more. A composition, such as an oil based drilling fluid, includes the reaction product of a carboxylic acid with at least two carboxylic moieties and a polyamine having an amine functionality of two or more.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present application is a continuation of prior U.S. application Ser.No. 12/870,227, filed Aug. 27, 2010 (now allowed), which is acontinuation of prior U.S. application Ser. No. 12/075,027, filed 7 Mar.2008, (now U.S. Pat. No. 7,799,742), each of which is herebyincorporated by reference in their entirety.

BACKGROUND OF THE INVENTION

Drilling fluids have been used since the very beginning of oil welldrilling operations in the United States and drilling fluids and theirchemistry are an important area for scientific and chemicalinvestigations. Certain uses and desired properties of drilling fluidsare reviewed in U.S. Patent Application 2004/0110642 and U.S. Pat. Nos.6,339,048 and 6,462,096, issued to the assignee of this application, theentire disclosures of which are incorporated herein by reference.

Nevertheless, the demands of the oil-well drilling environment requireincreasing improvements in rheology control over broad temperatureranges. This becomes particularly true, for example, as the search fornew sources of oil involves greater need to explore in deep water areasand to employ horizontal drilling techniques.

SUMMARY OF THE INVENTION

According to some embodiments, a method of providing a substantiallyconstant rheological profile of a drilling fluid over a temperaturerange of about 120° F. to about 40° F. includes adding a drilling fluidadditive to the drilling fluid, wherein the drilling fluid additiveconsists essentially of a reaction product of a carboxylic acid with atleast two carboxylic moieties, and a polyamine having an aminefunctionality of two or more.

In some embodiments, the carboxylic acid is a dimer fatty acid, such asa hydrogenated, partially hydrogenated or non-hydrogenated dimer acidswith from about 20 to about 48 carbon atoms. In some embodiments, thecarboxylic acid is a trimer fatty acid.

In some embodiments, the polyamine is polyethylene polyamine. In someembodiments, the polyamine includes ethylenediamine, diethylenetriamine,triethylenetriamine or tetrayethylenepentamine.

In certain embodiments, one or more emulsifiers is added to the drillingfluid. In some embodiments, an organoclay may be added to the drillingfluid. In some embodiments, a non-organoclay rheological additive may beadded to the drilling fluid. In some embodiments, a fluid loss reducingadditive may be added to the drilling fluid. In certain embodiments, asolvent is added to the drilling fluid.

In certain embodiments, the increase in high shear rate viscosity of thedrilling fluid is less than about 75% when the drilling fluid is cooledfrom about 120° F. to about 40° F. In some embodiments, the increase inhigh shear rate viscosity of the drilling fluid is less than about 60%when the drilling fluid is cooled from about 120° F. to about 40° F.

In some embodiments, less than about 2 ppb drilling fluid additive isadded to the drilling fluid. In certain embodiments, less than about 1.5ppb drilling fluid additive is added to the drilling fluid. In someembodiments, less than about 1.0 ppb drilling fluid additive is added tothe drilling fluid.

According to some embodiments, the reaction product has an averagemolecular weight of about 2,000 to about 2030. In some embodiments, thereaction product has an average molecular weight of about 2,010 to about2,020.

According to some embodiments, a method of providing a substantiallyconstant rheological profile of an oil-based drilling fluid over atemperature range of about 120° F. to about 40° F. includes adding adrilling fluid additive to the drilling fluid, wherein the drillingfluid additive comprises a reaction product of a carboxylic acid with atleast two carboxylic moieties; and a polyamine having an aminefunctionality of two or more, and wherein the drilling fluid additivehas an EC50 (72 h) value of greater than about 400 mg/l as determinedfrom the OECD 201 protocol using skeletonema costatum and an LC50 (96 h)value of greater than about 400 mg/kg as determined from the Parcom 1995protocol using scophthalmus maximus.

According to some embodiments, a method of providing a substantiallyconstant rheological profile of an oil-based drilling fluid over atemperature range of about 120° F. to about 40° F. includes adding adrilling fluid additive to the drilling fluid, wherein the drillingfluid additive comprises a reaction product of a carboxylic acid with atleast two carboxylic moieties; and a polyamine having an aminefunctionality of two or more, and wherein the drilling fluid additivehas an LC50 (48 h) value greater than about 1,000 mg/l as determinedfrom the ISO 14669 protocol of acartia tonsa and an LC50 (10 day)greater than about 5,000 mg/kg as determined from Parcom 1995 protocolusing corophium volutator.

According to some embodiments, a method of providing a substantiallyconstant rheological profile of an oil-based drilling fluid over atemperature range of about 120° F. to about 40° F. includes adding adrilling fluid additive to the drilling fluid, wherein the drillingfluid additive comprises a reaction product of a carboxylic acid with atleast two carboxylic moieties; and a polyamine having an aminefunctionality of two or more, and wherein the drilling fluid additivehas an environmental rating (Offshore Chemical Notification Scheme,“OCNS,” Group) of Class C, Class D, or Class E as defined by the Centrefor Environment, Fisheries and Aquaculture Science (“CEFAS”).

According to some embodiments, a composition includes a reaction productof a carboxylic acid with at least two carboxylic moieties and apolyamine having an amine functionality of two or more.

In some embodiments, an oil based drilling fluid includes a reactionproduct of a carboxylic acid with at least two carboxylic moieties and apolyamine having an amine functionality of two or more.

DETAILED DESCRIPTION OF THE EMBODIMENTS

In some embodiments, a drilling fluid additive includes a reactionproduct of (i) a carboxylic acid with at least two carboxylic moieties,and (ii) a polyamine having an amine functionality of two or more. Insome embodiments, the addition of a drilling fluid additive of thepresent invention to a drilling fluid provides a substantially constantrheological profile of a drilling fluid over a temperature range ofabout 120° F. to about 40° F.

Drilling Fluid Additive

Carboxylic Acids

Any carboxylic acid with at least two carboxylic moieties can be usedfor producing the reaction product component of the drilling fluidadditive. In some embodiments, the carboxylic acid is a dimer acid. Insome embodiments, the carboxylic acid includes dimer acids of C₁₆ and/orC₁₈ fatty acid. In certain embodiments, such dimer acids are fullyhydrogenated, partially hydrogenated, or not hydrogenated at all. Insome embodiments, dimer acids include products resulting from thedimerization of C₁₆ to C₁₈ unsaturated fatty acids.

In some embodiments, the dimer acids have an average of about 18 toabout 48 carbon atoms. In some embodiments, the dimer acids have anaverage of about 20 to 40 carbon atoms. In one embodiment, the dimeracids have an average of about 36 carbon atoms.

Suitable dimer acids may be prepared from C₁₈ fatty acids, such as oleicacids. Examples of suitable dimer acids are described in U.S. Pat. Nos.2,482,760, 2,482,761, 2,731,481, 2,793,219, 2,964,545, 2,978,468,3,157,681, and 3,256,304, the entire disclosures of which areincorporated herein by reference.

Examples of suitable dimer acids include the Empol® product lineavailable from Cognis Inc. (eg: Empol® 1061), and Pripol® dimer acidsavailable from Uniqema (eg: Pripol® 1013).

In some embodiments, the carboxylic acid includes a trimer acid. In someembodiments, trimer acids are included in the drilling fluid additivethough the addition of commercial dimer acid products such as Empol®1061 or Pripol® 1013. In some embodiments, the carboxylic acid does notinclude a trimer acid.

Many commercially available dimer fatty acids contain a mixture ofmonomer, dimer, and trimer acids. In some embodiments, the dimer fattyacid has a specific dimer content as increased monomer and trimerconcentration may hinder the additive's performance. In someembodiments, commercial products are distilled or otherwise processed toensure certain suitable dimer content. In some embodiments, a suitabledimer acid has a dimer content of at least about 80%. In someembodiments, suitable dimer acid has a dimer content of at least about90%. An example of a suitable dimer acid includes Empol® 1061, which hasa dimer acid content of 92.5%-95.5%, a trimer acid content of 1.5%-3.5%and a monoacid content of 2.5%-5.0%.

Polyamines

According to some embodiments, polyamines having an amine functionalityof two or more are used for the preparation of a reaction product thatmay be incorporated in the drilling fluid additive. In some embodiments,polyamines from the family of polyethylene polyamines having an aminefunctionality of two or more are used.

Di-, tri-, and polyamines and their combinations may be suitable for usein the drilling fluid additive. Examples of such amines may includeethylenediamine, diethylenetriamine, triethylenetetramine,tetraethylenepentamine and other members of this series. In someembodiments, branched polyamines and polyamines made with differentalkyl groups are used.

In some embodiments, a suitable triamine is diethylenetramine (DETA).DETA has been assigned a CAS No. of 111-40-0 and is commerciallyavailable from Huntsman International.

Making the Reaction Product

Specifics on processing of polyamines and carboxylic acids are wellknown and can be used in making the reaction product for incorporationin the drilling fluid additive. In some embodiments, the molar ratiobetween the amine functional group and carboxyl functional group isabout 4:1 to about 1:1. In some embodiments, the molar ratio between theamine functional group and carboxyl functional group is about 1.5:1 toabout 3:1. In some embodiments, the molar ratio between the aminefunctional group and carboxyl functional group is about 2:1. Forexample, mixtures of more than one dimer acid and/or more than onepolyamine can be used. In some embodiments, these reactions may generateimidazolines and other side products.

In some embodiments, the reaction product has an average molecularweight of about 1,990 to about 2,040. In some embodiments, the reactionproduct has an average molecular weight of about 2,000 to about 2,030.In other embodiments, the reaction product has an average molecularweight of about 2,010 to about 2,020. In some embodiments, the reactionproduct has an average molecular weight of about 2,014.

Additional Components

Optionally, additional ingredients may be added to the drilling fluidadditive or may be added directly to the drilling mud itself. In someembodiments, a fatty acid amide is added directly to the drilling mud.

In some embodiments, suitable fatty amides are amides of fatty acidsthat are sparingly soluble in drilling fluids. In some embodiments,suitable fatty amides include high temperature melting amides of fattyacids that are sparingly soluble in drilling muds, such as the Amid®product line by Akzo Nobel. In some embodiments, alkoxylated fattyamides, such as the Ethomid® product line by Akzo Nobel can be used. Forexample, a suitable alkoxylated fatty amide may include Ethomid® O/17which has 7 moles of EO on oleamide.

Preparation of the Drilling Fluids

In some embodiments, compositions according to the present invention maybe used as an additive to oil- or synthetic-based drilling fluids. Insome embodiments, compositions according to the present invention may beused as an additive for oil- or synthetic-based invert emulsion drillingfluids employed in a variety of drilling applications.

The term oil- or synthetic-based drilling fluid is defined as a drillingfluid in which the continuous phase is hydrocarbon based. Oil- orsynthetic-based drilling fluids formulated with over 5% water or brinemay be classified as oil- or synthetic-based invert emulsion drillingfluids. In some embodiments, oil- or synthetic-based invert emulsiondrilling fluids may contain water or brine as the discontinuous phase inany proportion up to about 50%. Oil muds may include invert emulsiondrilling fluids as well as all oil based drilling fluids usingsynthetic, refined or natural hydrocarbon base as the external phase.

According to some embodiments, a process for preparing invert emulsiondrilling fluids (oil muds) involves using a mixing device to incorporatethe individual components making up that fluid. In some embodiments,primary and secondary emulsifiers and/or wetting agents (surfactant mix)are added to the base oil (continuous phase) under moderate agitation.The water phase, typically a brine, may be added to the baseoil/surfactant mix along with alkalinity control agents and acid gasscavengers. In some embodiments, rheological additives as well as fluidloss control materials, weighting agents and corrosion inhibitionchemicals may also be included. The agitation may then be continued toensure dispersion of each ingredient and homogenize the resultingfluidized mixture.

Base Oil/Continuous Phase

According to some embodiments, diesel oil, mineral oil, synthetic oil,vegetable oil, fish oil, paraffinics, and/or ester-based oils can all beused as single components or as blends.

Brine Content

In some embodiments, water in the form of brine is often used in formingthe internal phase of the drilling fluids. According to someembodiments, water can be defined as an aqueous solution which cancontain from about 10 to 350,000 parts-per-million of metal salts suchas lithium, sodium, potassium, magnesium, cesium, or calcium salts. Insome embodiments, brines used to form the internal phase of a drillingfluid according to the present invention can also contain about 5% toabout 35% by weight calcium chloride and may contain various amounts ofother dissolved salts such as sodium bicarbonate, sodium sulfate, sodiumacetate, sodium borate, potassium chloride, sodium chloride or formates(such as sodium, calcium, or cesium). In some embodiments, glycols orglycerin can be used in place of or in addition to brines.

In some embodiments, the ratio of water (brine) to oil in the emulsionsaccording to the present invention may provide as high a brine contentas possible while still maintaining a stable emulsion. In someembodiments, suitable oil/brine ratios may be in the range of about 97:3to about 50:50. In some embodiments, suitable oil/brine ratios may be inthe range of about 90:10 to about 60:40, or about 80:20 to about 70:30.In some embodiments, the preferred oil/brine ratio may depend upon theparticular oil and mud weight. According to some embodiments, the watercontent of a drilling fluid prepared according to the teachings of theinvention may have an aqueous (water) content of about 0 to 50 volumepercent.

Organoclays/Rheological Additives Other than Organoclays

In some embodiments, the drilling fluid additive includes an organoclay.According to some embodiments, organoclays made from at least one ofbentonite, hectorite and attapulgite clays are added to the drillingfluid additive. There are a large number of suppliers of such clays inaddition to Elementis Specialties' BENTONE® product line includingRockwood Specialties, Inc. and Sud Chemie GmbH. In addition to or inplace of organoclays, polymeric rheological additives, such asTHIXATROL® DW can be added to the drilling fluid. Examples of suitablepolymeric rheological additives are described in U.S. Patent ApplicationNo. 2004-0110642, which is incorporated by reference herein in itsentirety.

Emulsifiers

According to some embodiments, an emulsifier can also be added to thedrilling fluid in order to form a more stable emulsion. The emulsifiermay include organic acids, including but not limited to the monocarboxylalkanoic, alkenoic, or alkynoic fatty acids containing from 3 to 20carbon atoms, and mixtures thereof. Examples of this group of acidsinclude stearic, oleic, caproic, capric and butyric acids. In someembodiments, adipic acid, a member of the aliphatic dicarboxylic acids,can also be used. According to some embodiments, suitable surfactants oremulsifiers include fatty acid calcium salts and lecithin. In otherembodiments, suitable surfactants or emulsifiers include oxidized talloil, polyaminated fatty acids, and partial amides of fatty acids.

In some embodiments, heterocyclic additives such as imidazolinecompounds may be used as emulsifiers and/or wetting agents in thedrilling muds. In other embodiments, alkylpyridines may be used to asemulsifiers and/or wetting agents in the drilling muds.

Industrially obtainable amine compounds for use as emulsifiers may bederived from the epoxidation of olefinically unsaturated hydrocarboncompounds with subsequent introduction of the N function by addition tothe epoxide group. The reaction of the epoxidized intermediatecomponents with primary or secondary amines to form the correspondingalkanolamines may be of significance in this regard. In someembodiments, polyamines, particularly lower polyamines of thecorresponding alkylenediamine type, are also suitable for opening of theepoxide ring.

Another class of the oleophilic amine compounds that may be suitable asemulsifiers are aminoamides derived from preferably long-chaincarboxylic acids and polyfunctional, particularly lower, amines of theabove-mentioned type. In some embodiments, at least one of the aminofunctions is not bound in amide form, but remains intact as apotentially salt-forming basic amino group. The basic amino groups,where they are formed as secondary or tertiary amino groups, may containhydroxyalkyl substituents and, in particular, lower hydroxyalkylsubstituents containing up to 5 and in some embodiments up to 3C atomsin addition to the oleophilic part of the molecule.

According to some embodiments, suitable N-basic starting components forthe preparation of such adducts containing long-chain oleophilicmolecule constituents may include but are not limited tomonoethanolamine or diethanolamine.

Weight Agents

In some embodiments, weighting materials are also used to weight thedrilling fluid additive to a desired density. In some embodiments, thedrilling fluid is weighted to a density of about 8 to about 18 poundsper gallon and greater. Suitable weighting materials may include barite,ilmenite, calcium carbonate, iron oxide and lead sulfide. In someembodiments, commercially available barite is used as a weightingmaterial.

Filtrate Reduces

In some embodiments, fluid loss control materials are added to thedrilling fluid to control the seepage of drilling fluid into theformation. In some embodiments, fluid loss control materials areliganite-based or asphalt-based. Suitable filtrate reducers may includeamine treated lignite, gilsonite and/or elastomers such as styrenebutadiene.

Blending Process

In some embodiments, drilling fluids may contain about 0.1 pounds toabout 15 pounds of the drilling fluid additive per barrel of fluids. Inother embodiments, drilling fluids may contain about 0.1 pounds to about10 pounds of the drilling fluid additive per barrel of fluids, and instill other embodiments, drilling fluids may contain about 0.1 pounds toabout 5 pounds of the drilling fluid additive per-barrel of fluids.

As shown above, a skilled artisan will readily recognize that additionaladditives such as weighting agents, emulsifiers, wetting agents,viscosifiers, fluid loss control agents, and other agents can be usedwith a composition according to the present invention. A number of otheradditives besides rheological additives regulating viscosity andanti-settling properties can also be used in the drilling fluid so as toobtain desired application properties, such as, for example,anti-settling agents and fluid loss-prevention additives.

In some embodiments, the drilling fluid additive can be cut or dilutedwith solvent to vary the pour point or product viscosity. Any suitablesolvent or combination of solvents may be used. Suitable solvents mayinclude but are not limited to: diesel, mineral or synthetic oils, blockcopolymers of EO/PO and/or styrene/isoprene, glycols includingpolyalkylene glycols, alcohols including polyethoxylated alcohols,polyethoxylated alkyl phenols or polyethoxylated fatty acids, variousethers, ketones, amines, amides, and esters.

Method of Use

In some embodiments, a drilling fluid additive may be added to adrilling fluid. In some embodiments, the drilling fluid additive may beadded to a drilling fluid in combination with other additives, such asThixatrol® DW and Bentone® 155, both by Elementis Specialties.

In some embodiments, a drilling fluid additive is added to a drillingfluid in an amount of about 0.1 ppb to about 30 ppb. In otherembodiments, a drilling fluid additive is added to a drilling fluid inan amount of about 0.25 ppb to about 15.0 ppb. In other embodiments, adrilling fluid additive is added to a drilling fluid in an amount ofabout 0.25 ppb to about 5 ppb. In some embodiments, a drilling fluidadditive is added to a drilling fluid in an amount of about 0.5 ppb. Insome embodiments, a drilling fluid additive is added to a drilling fluidin an amount of about 0.75 ppb. In some embodiments, a drilling fluidadditive is added to a drilling fluid in an amount of about 1.0 ppb. Insome embodiments, a drilling fluid additive is added to a drilling fluidin an amount of about 1.5 ppb. In some embodiments, a drilling fluidadditive is added to a drilling fluid in an amount of about 2.0 ppb. Insome embodiments, a smaller amount of a drilling fluid additive of thepresent invention is required to achieve comparable rheologicalstability results as a known drilling fluid additive.

In some embodiments, the addition of the drilling fluid additive to adrilling fluid results in a substantially constant rheological profilethroughout a temperature range. A substantially constant rheologicalprofile of a drilling fluid may be determined by the change in viscosityof the drilling fluid as the temperature of the drilling fluid isreduced from bottom hole temperature typically encountered in deep waterdrilling, to temperatures typically encountered in the riser in deepwater drilling. In some embodiments, the rheological profile of adrilling fluid is measured in terms of the increase in high rate (600rpm) Fann 35A viscosity of the drilling fluid when the drilling fluid iscooled from about 120° F. to about 40° F. In some embodiments, asubstantially constant rheological profile is achieved when the changein high shear rate viscosity of a drilling fluid is less than about 90%over a temperature range of about 120° F. to about 40° F. In otherembodiments, a substantially constant rheological profile is achievedwhen the change in high shear rate viscosity of a drilling fluid is lessthan about 85% over a temperature range of about 120° F. to about 40° F.In some embodiments, a substantially constant rheological profile isachieved when the change in high shear rate viscosity is less than about80% over a temperature range of about 120° F. to about 40° F. In someembodiments, a substantially constant rheological profile is achievedwhen the change in high shear rate viscosity is less than about 75% overa temperature range of about 120° F. to about 40° F. In otherembodiments, a substantially constant rheological profile is achievedwhen the change in high shear rate viscosity of a drilling fluid is lessthan about 70% over a temperature range of about 120° F. to about 40° F.In other embodiments, a substantially constant rheological profile isachieved when the change in high shear rate viscosity of a drillingfluid is less than about 65% over a temperature range of about 120° F.to about 40° F. In other embodiments, a substantially constantrheological profile is achieved when the change in high shear rateviscosity of a drilling fluid is less than about 60% over a temperaturerange of about 120° F. to about 40° F. In other embodiments, asubstantially constant rheological profile is achieved when the changein high shear rate viscosity of a drilling fluid is less than about 55%over a temperature range of about 120° F. to about 40° F. In otherembodiments, a substantially constant rheological profile is achievedwhen the change in high shear rate viscosity of a drilling fluid is lessthan about 50% over a temperature range of about 120° F. to about 40° F.The viscosity of the drilling fluid may be measured according to API RP13B procedures.

In some embodiments, a drilling fluid according to the present inventionmay have a lower viscosity at 40° F. than conventional muds formulatedwith sufficient organoclay to provide suspension at bottom holetemperatures. When used in drilling operations, drilling fluidsaccording to the present invention may allow the use of a lower pumpingpower to pump drilling muds through long distances, thereby reducingdown-hole pressures. Consequently, in some embodiments, whole mud loss,fracturing and damage of the formation are all minimized. In someembodiments, drilling fluids according to the present invention maymaintain the suspension characteristics typical of higher levels oforganoclays at higher temperatures. Such suspension characteristics mayreduce the tendency of the mud to sag. Sag may include the migration ofweight material, resulting in a higher density mud at a lower fluidfraction and a lower density mud at a higher fluid fraction. A reductionof sag may be valuable in both deep water drilling as well asconventional (non deep water) drilling. The present invention may beparticularly useful in deep water drilling when the mud is cooled in theriser. A mud using a drilling fluid additive according to the presentinvention will maintain a reduced viscosity increase in the riser whencompared to drilling fluids containing conventional rheologicaladditives.

Environmental Effects

In some embodiments, a drilling fluid additive of the present inventionis environmentally acceptable. In some embodiments, a drilling fluidadditive of the present invention is environmentally acceptable in termsof at least one of aerobic biodegradation in seawater, marineinvertebrate toxicity, marine algal inhibition, marine sedimentre-worker toxicity, and/or juvenile turbot fish toxicity.

When tested according to ISO 14669 protocol using acartia tonsa, adrilling fluid additive of some embodiments of the present inventionresults in a LC50 (48 h) of greater than about 1000 mg/l; in someembodiments a drilling fluid additive of the present invention resultsin a LC50 (48 h) of greater than about 1500 mg/l; in some embodiments adrilling fluid additive of the present invention results in a LC50 (48h) of greater than about 1750 mg/l; and in some embodiments a drillingfluid additive of the present invention results in a LC50 (48 h) ofgreater than about 2000 mg/l. According to the ISO 14669 protocol, theLC50 (48 h) of a substance is the lowest concentration of the substanceto kill 50% of the chosen marine invertebrate during a 48 hour test.

When tested for marine algal inhibition under the OECD 201 protocolusing skeletonema costatum, a drilling fluid additive of someembodiments of the present invention results in a EC50 (72 h) value ofgreater than about 400 mg/l; in some embodiments the EC50 (72 h) valueis greater than about 600 mg/l; in some embodiments the EC50 (72 h)value is greater than about 700 mg/l; and in some embodiments the EC50(72 h) value is about greater than about 730 mg/l. The OECD 201 protocoldefines EC50 as the concentration of test substance which results in a50% reduction in either growth or growth rate relative to the control.

When tested according to the PARCOM (Paris Commission) 1995 protocolusing corophium volutator, a drilling fluid additive of some embodimentsof the present invention results in a LC50 (10 day) of greater thanabout 5,000 mg/kg; in some embodiments a drilling fluid additive of thepresent invention results in a LC50 (10 day) of greater than about 7,500mg/kg; in some embodiments a drilling fluid additive of the presentinvention results in a LC50 (10 day) of greater than about 9,000 mg/kg;and in some embodiments a drilling fluid additive of the presentinvention results in a LC50 (10 day) of greater than about 10,000 mg/kg.According to the PARCOM 1995 protocol, the LC50 (10 day) of a substanceis the lowest concentration of the substance to kill 50% of the chosenspecies during a 10 day test.

When tested according to the PARCOM (Paris Commission) 1995 protocolusing scophthalmus maximus, a drilling fluid additive of someembodiments of the present invention results in a LC50 (96 h) of greaterthan about 400 mg/kg; in some embodiments a drilling fluid additive ofthe present invention results in a LC50 (96 h) of greater than about 600mg/kg; in some embodiments a drilling fluid additive of the presentinvention results in a LC50 (96 h) of greater than about 700 mg/kg; andin some embodiments a drilling fluid additive of the present inventionresults in a LC50 (96 h) of greater than about 730 mg/kg. According tothe PARCOM 1995 protocol, the LC50 (96 h) of a substance is the lowestconcentration of the substance to kill 50% of the chosen species duringa 96 hour test.

In some embodiments, a drilling fluid additive of the present inventionhas a Class E environmental rating. In some embodiments, a drillingfluid additive of the present invention has a Class D environmentalrating. In some embodiments, a drilling fluid additive of the presentinvention has a Class C environmental rating. In some embodiments, adrilling fluid additive of the present invention has a Class Benvironmental rating.

EXAMPLES

A drilling fluid was prepared based on the formulation in Table 1 foruse in the following Examples.

TABLE 1 Drilling Fluid Formulation Fluid Formulation Lbs./BBL SyntheticBased Oil 186 Primary Emulsifier 4 Secondary Emulsifier 2 30% CalciumChloride Brine 75 Lime 4 Rheological Additive See Tables forConcentrations Barite 215

All fluids were prepared and tested according to standard API RP 13B mudpreparation guidelines using standard malt cups and a 5 spindle HamiltonBeach multimixer.

Example 1 Prior Art

BENTONE 155®, an organoclay, was added to the drilling fluid of Table 1in amounts of 2.5 ppb and 5.0 ppb. The viscosity measurements at variousshear rates and temperatures of the drilling fluid with the organoclayare included in Table 2. Table 2 shows that an oil-based drilling fluidincorporating 2.5 ppb organoclay (BENTONE 155®) alone as a rheologicalmodifier exhibited a high shear rate (600 rpm) viscosity increase of113.0% (54 to 115) when the temperature was reduced from 120° F. to 40°F., and a low shear rate (6 rpm) viscosity increase of 350.0% (4 to 18)when the temperature was reduced from 120° F. to 40° F.

An oil-based drilling fluid incorporating 5.0 ppb organoclay exhibited ahigh shear rate viscosity increase of 112.8% (78 to 166) when thetemperature was reduced from 120° F. to 40° F. and a low shear rateviscosity increase of 240.0% (10 to 34) when the temperature was reducedfrom 120° F. to 40° F.

TABLE 2 BENTONE ® 155 Concentration Evaluation Additive BENTONE ® 155BENTONE ® 155 Additive(s) Concentration 2.5 ppb 2.5 ppb 2.5 ppb 5.0 ppb5.0 ppb 5.0 ppb OFI 800 Viscosity 120° F. 40° F. Percent 120° F. 40° F.Percent Test Test change Test Test change 600 RPM 54 115 113.0% 78 166112.8% Reading 300 RPM 31 73 135.5% 50 112 124.0% Reading 200 RPM 22 57159.1% 39 91 133.3% Reading 100 RPM 15 40 166.7% 27 66 144.4% Reading 6RPM 4 18 350.0% 10 34 240.0% Reading 3 RPM 3 16 433.3% 9 32 255.6%Reading Apparent 27 58 114.8% 39 83 112.8% Visc., cPs Plastic Visc., 2342 82.6% 28 54 92.9% cPs Yield Point, 8 31 287.5% 22 58 163.6% Lbs/100ft{circumflex over ( )}2

Example 2 Comparative

2.5 ppb BENTONE 155® was combined with a drilling fluid additiveincluding ethoxylated amine mixed with the reaction product of a dimeracid and diethylene triamine (DETA) in the drilling fluid of Table 1.The viscosity measurements at various shear rates and temperatures ofthe drilling fluid with the organoclay and drilling fluid additive areincluded in Table 3. Table 3 shows that an oil-based drilling fluidincorporating 2.5 ppb organoclay (BENTONE 155®) and 0.5 ppb of thedrilling fluid additive of this Example exhibited a high shear rate (600rpm) viscosity increase of 59.3% (54 to 86) when the temperature wasreduced from 120° F. to 40° F., and a low shear rate (6 rpm) viscosityincrease of 116.7% (6 to 13) when the temperature was reduced from 120°F. to 40° F.

An oil-based drilling fluid incorporating 2.5 ppb organoclay and 1.25ppb of the drilling fluid additive of this Example exhibited a highshear rate viscosity increase of 63.1% (65 to 106) when the temperaturewas reduced from 120° F. to 40° F. and a low shear rate viscosityincrease of 25.0% (8 to 10) when the temperature was reduced from 120°F. to 40° F.

An oil-based drilling fluid incorporating 2.5 ppb organoclay and 2.5 ppbof the drilling fluid additive of this Example exhibited a high shearrate viscosity increase of 57.1% (77 to 121) when the temperature wasreduced from 120° F. to 40° F. and a low shear rate viscosity decreaseof 44.4% (9 to 5) when the temperature was reduced from 120° F. to 40°F.

TABLE 3 BENTONE ® 155 with Dimer Acid/DETA/EOamine Product ConcentrationEvaluation Additive BENTONE ® 155 with Dimer BENTONE ® 155 with DimerBENTONE ® 155 with Dimer Acid/DETA/EOamine Product Acid/DETA/EOamineProduct Acid/DETA/EOamine Product Additive(s) Concentration 2.5 ppb/ 2.5ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 0.5ppb 0.5 ppb 0.5 ppb 1.25 ppb 1.25 ppb 1.25 ppb 2.5 ppb 2.5 ppb 2.5 ppbOFI 800 Viscosity 120° F. 40° F. Percent 120° F. 40° F. Percent 120° F.40° F. Percent Test Test change Test Test change Test Test change 600RPM 54 86 59.3% 65 106 63.1% 77 121 57.1% Reading 300 RPM 33 54 63.6% 3963 61.5% 47 66 40.4% Reading 200 RPM 24 42 75.0% 28 45 60.7% 35 47 34.3%Reading 100 RPM 16 27 68.8% 19 28 47.4% 22 26 18.2% Reading 6 RPM 6 13116.7% 8 10 25.0% 9 5 −44.4% Reading 3 RPM 6 12 100.0% 7 9 28.6% 8 4−50.0% Reading Apparent 27 43 59.3% 33 53 60.6% 39 61 56.4% Visc., cPsPlastic Visc., 21 32 52.4% 26 43 65.4% 30 55 83.3% cPs Yield Point, 1222 83.3% 13 20 53.8% 17 11 −35.3% Lbs/100 ft{circumflex over ( )}2

Example 3 Comparative

2.5 ppb BENTONE 155® was combined with a drilling fluid additiveincluding the reaction product of a dimer acid and diethylene triamine(DETA) in the drilling fluid of Table 1. The viscosity measurements atvarious shear rates and temperatures of the drilling fluid with theorganoclay and drilling fluid additive are included in Table 4. Table 4shows that an oil-based drilling fluid incorporating 2.5 ppb organoclay(BENTONE 155®) and 0.5 ppb of the drilling fluid additive of thisExample exhibited a high shear rate (600 rpm) viscosity increase of55.7% (61 to 95) when the temperature was reduced from 120° F. to 40°F., and a low shear rate (6 rpm) viscosity increase of 62.5% (8 to 13)when the temperature was reduced from 120° F. to 40° F.

An oil-based drilling fluid incorporating 2.5 ppb organoclay and 0.75ppb of the drilling fluid additive of this Example exhibited a highshear rate viscosity increase of 52.2% (67 to 102) when the temperaturewas reduced from 120° F. to 40° F. and a low shear rate viscosityincrease of 40.0% (10 to 14) when the temperature was reduced from 120°F. to 40° F.

An oil-based drilling fluid incorporating 2.5 ppb organoclay and 1.0 ppbof the drilling fluid additive of this Example exhibited a high shearrate viscosity increase of 47.9% (73 to 108) when the temperature wasreduced from 120° F. to 40° F. and a low shear rate viscosity increaseof 25.0% (12 to 15) when the temperature was reduced from 120° F. to 40°F.

TABLE 4 BENTONE ® 155 with Dimer Acid/DETA Product ConcentrationEvaluation Additive BENTONE ® 155 with Dimer BENTONE ® 155 with DimerBENTONE ® 155 with Dimer Acid/DETA Product Acid/DETA Product Acid/DETAProduct Additive(s) Concentration 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 2.5 ppb/ 0.5 ppb 0.5 ppb 0.5 ppb0.75 ppb 0.75 ppb 0.75 ppb 1.0 ppb 1.0 ppb 1.0 ppb OFI 800 Viscosity120° F. 40° F. Percent 120° F. 40° F. Percent 120° F. 40° F. PercentTest Test change Test Test change Test Test change 600 RPM 61 95 55.7%67 102 52.2% 73 108 47.9% Reading 300 RPM 38 59 55.3% 42 65 54.8% 45 6748.9% Reading 200 RPM 29 46 58.6% 32 53 65.6% 36 53 47.2% Reading 100RPM 19 30 57.9% 21 33 57.1% 24 34 41.7% Reading 6 RPM 8 13 62.5% 10 1440.0% 12 15 25.0% Reading 3 RPM 7 12 71.4% 9 13 44.4% 11 14 27.3%Reading Apparent 31 48 54.8% 34 51 50.0% 37 54 45.9% Visc., cPs PlasticVisc., 23 36 56.5% 25 37 48.0% 28 41 46.4% cPs Yield Point, 15 23 53.3%17 28 64.7% 17 26 52.9% Lbs/100 ft{circumflex over ( )}2

Example 4

A drilling fluid additive was prepared from the reaction product of adimer acid and diethylene triamine (DETA). A second drilling fluidadditive was prepared from the reaction product of a dimer acid,diethylene triamine (DETA), and an alkoxylated amine. The additives weretested according to several environmental protocols. The test resultsare listed in Table 5 below.

TABLE 5 Environmental Testing Results Dimer Acid/DETA/ Dimer Acid/DETAAlkoxylated Amine Test Suite Species Protocol Product Product Marineinvertebrate Acartia tonsa ISO 14669 LC50(48 h) > LC50(48 h): 2.0 mg/ltoxicity 2000 mg/l Marine algal inhibition Skeletonema costatum OECD 201EC50(72 h): 730 mg/l EC50(72 h): 0.23 mg/l Marine sediment Corophiumvolutator PARCOM 1995 LC50(10 day) > LC50(10 day): 274.3 mg/kg reworkertoxicity 10,000 mg/kg Juvenile turbot fish Scophthalmus maximus PARCOM1995 LC50(96 h) > LC50(96 h): 6.4 mg/kg toxicity 730 mg/kg

The additives were tested according to the ISO 14669 protocol for marineinvertebrate toxicity using acartia tonsa. The dimer acid/DETA productdemonstrated a much lower toxicity. The results show that more than2,000 mg/l of the dimer acid/DETA product was required in order to kill50% of the arcartia tonsa over 48 hours, whereas a concentration of only2.0 mg/l of the dimer acid/DETA/alkoxylated amine product was requiredto accomplish the same result.

The additives were tested for marine algal inhibition under the OECD 201protocol, using skeletonema costatum. The dimer acid/DETA productdemonstrated a significantly lower inhibition rate than the dimeracid/DETA/alkoxylated amine product. As shown in Table 5, aconcentration of more than 730 mg/l of the dimer acid/DETA product wasrequired in order to inhibit the skeletonema costatum by 50% over 72hours, whereas a concentration of only 0.23 mg/l of the dimeracid/DETA/alkoxylated amine was required to accomplish the same result.

The dimer acid/DETA product also demonstrated lower toxicity than thedimer acid/DETA/alkoxylated amine product when tested for marinesediment reworker toxicity according to PARCOM (Paris Commission) 1995,using corophium volutator. As shown in Table 5, a concentration of morethan 10,000 mg/kg of the dimer acid/DETA product was required in orderto kill 50% of the corophium volutator over 10 days, whereas aconcentration of only 274.3 mg/kg of the dimer acid/DETA/alkoxylatedamine product was required to accomplish the same result.

Similarly, the dimer acid/DETA product demonstrated lower toxicity thanthe dimer acid/DETA/alkoxylated amine product when tested for juvenileturbot fish toxicity according to the PARCOM 1995 protocol, usingscophthalmus maximus. A concentration of more than 730 mg/kg of thedimer acid/DETA product was required in order to kill 50% of thescophthalmus maximus over 96 hours, whereas a concentration of only 6.4mg/kg of the dimer acid/DETA/alkoxylated amine product was required toaccomplish similar results.

The foregoing description and examples have been set forth merely toillustrate the invention and are not intended to be limiting. Sincemodifications of the disclosed embodiments incorporating the spirit andsubstance of the invention may occur to persons skilled in the art, theinvention should be construed broadly to include all variations fallingwithin the scope of the appended claims and equivalents thereof.

1. A method of improving the suspension characteristics of an oil-baseddrilling fluid comprising adding a drilling fluid additive to thedrilling fluid, wherein the drilling fluid additive consists essentiallyof a polyamide having repeat units of (a) a carboxylic unit with atleast two carboxylic moieties; and (b) a polyamine unit having an aminefunctionality of two or more, wherein the oil-based drilling fluidexhibits a rheological profile corresponding to a change in Fann readingno more than 50-70 units as shear rate is varied from 600 rpm to 6 rpmat a temperature of 120° F.
 2. The method of claim 1, wherein thecarboxylic unit is derived from a dimer fatty acid.
 3. The method ofclaim 2, wherein the dimer fatty acid is selected from the groupconsisting of hydrogenated, partially hydrogenated and non-hydrogenatedfatty dimer acids with from about 20 to about 48 carbon atoms.
 4. Themethod of claim 2, wherein the dimer fatty acid is selected from thegroup consisting of a C16 dimer fatty acid, a C18 dimer fatty acid andmixtures thereof.
 5. The method of claim 1, wherein the carboxylic acidunit is derived from a mixture of a dimer fatty acid and a trimer fattyacid.
 6. The method of claim 1, wherein the polyamine unit is derivedfrom a polyethylene polyamine.
 7. The method of claim 6, wherein thepolyamine is selected from the group consisting of ethylenediamine,diethylenetriamine, triethylenetriamine and tetrayethylenepentamine. 8.The method of claim 6, wherein the polyamine is diethylenetriamine. 9.The method of claim 1, further comprising adding one or more emulsifiersto the drilling fluid.
 10. The method of claim 1, further comprisingadding an organoclay to the drilling fluid.
 11. The method of claim 1,further comprising adding to the drilling fluid one or more of: a fluidloss reducing additive and a weight agent.
 12. The method of claim 1,comprising adding less than about 2 ppb drilling fluid additive to thedrilling fluid.
 13. The method of claim 1, wherein the polyamide has anaverage molecular weight of about 2,000 to about 2030.